BBakken SubsurfaceNorth Dakota well index

NDIC file 39270 · API 33-053-09934-00-00

PORTER 25-36 XE 1H

Operated by DEVON ENERGY WILLISTON, L.L.C. · McKenzie County, North Dakota

Active (A)Oil and gasSpud 2022

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
ALEXANDER
Spud date
Total depth
21,487 ft
Legal location
SWSE Sec 23 T151N R101W
Footages
476 ft FSL · 1,798 ft FEL
County
McKenzie County
NDIC file no.
39270
API no.
33-053-09934-00-00

Location & navigation

Navigate with Google MapsDriving directions to the well headOpen in Google MapsSatellite view of the padOpen in Apple Maps

47.87858, -103.56922

Published surface location (NAD83). A horizontal well's lateral can run up to three miles from this point.

See it in 3D

Open in the regional 3D viewerSurveyed well path, operator and production; Bakken-system horizontals onlyBakken Subsurface 3DBasin-wide production playback

Production

39 months reported, Jun 2023 to Aug 2026, BAKKEN pool.

Cumulative oil342KbblJun ’23 to Aug ’26 · 39 of 39 months known
Peak oil rate2,341bbl/dJul 2023 · 30,431 bbl in 13 days
Oil, last 12 months77Kbbl+152% against the 12 before
Gas–oil ratio, last 12 months1,785scf/bblfirst year 1,846 scf/bbl
Water cut, last 12 months79%first year 62% · 764K bbl water in all
Gas sold, last 12 months90%of gas produced · 11.5K mcf reported flared
01,0002,0003,000Oil bbl/d165Jun ’23Dec ’23Jun ’24Dec ’24Jun ’25Dec ’25Jun ’26

Early time

First reported month
Jun 2023
Months to peak
3 (Aug 2023)
Peak month rate
2,341 bbl/d on 13 days
First 3 months, oil
78,046 bbl
First 6 months, oil
160,734 bbl
First 12 months, oil
217,365 bbl
First 24 months, oil
264,037 bbl
Share of cumulative in year 1
64%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
165 bbl/d
Latest rate as share of peak
7.0%
Uptime, last 12 months
99% of days
Cumulative gas
712K mcf
Cumulative water
764K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
6,4608,92532,444302151,38283%
7,06910,42131,127312281,47481%
6,8739,37626,653282451,36479%
7,07410,31125,612292441,45878%
7,82612,84526,445312521,64177%
6,83112,07020,238282441,76775%
7,10713,98022,562312291,96776%
6,53313,76720,661302182,10776%
5,73213,47720,223311852,35178%
5,49711,96822,995301832,17781%
4,8708,99024,068311571,84683%
5,10411,25214,058311652,20573%

As first reported to NDIC in each month's report (NDIC Monthly Production Reports, Jan 2003 to Aug 2026). Operators amend past months later and the published reports are not updated, so a month can differ from the current record. A blank or missing month is unknown, not zero, and a cumulative over such months is a lower bound; two pools reported in one month are summed. Rates per producing day divide the month's volume by the days reported, so a month reported without producing days has no rate. Gas–oil ratio is gas produced over oil produced; water cut is water over oil plus water. Months from Jan 2003 to Apr 2015 are read from the Division's PDF reports, which print no flared gas and list a well in a unitized pool only inside its unit's total.

Spacing units

Units whose published footprint holds at least 660 ft of this well's surveyed lateral. Allowances are facts extracted from signed NDIC orders, machine-extracted and not human-reviewed.

Nearby wells

Closest published well heads within 3 miles; wells on one pad share a location.

Other published attributes (1)
symbolA-OG

DMR shapefile columns not shown above, unchanged.